Integrated coordination scheduling framework of electricity-natural gas systems considering electricity transmission N − 1 contingencies and gas dynamics

Abstract

This paper discusses a security-constrained integrated coordination scheduling framework for an integrated electricity-natural gas system (IEGS), in which both tight interdependence between electricity and natural gas transmission networks and their distinct dynamic characteristics at different timescales are fully considered. The proposed framework includes two linear programming models. The first one focuses on hour-based steady-state coordinated economic scheduling on power outputs of electricity generators and mass flow rates of natural gas sources while considering electricity transmission N -1 contingencies. Using the steady-state mass flow rate solutions of gas sources as the initial value, the second one studies second-based slow gas dynamics and optimizes pressures of gas sources to ensure that inlet gas pressure of gas-fired generator is within the required pressure range at any time between two consecutive steady-state scheduling. The proposed framework is validated via an IEGS consisting of an IEEE 24-bus electricity network and a 15-node 14-pipeline natural gas network coupled by gasfired generators. Numerical results illustrate the effectiveness of the proposed framework in coordinating electricity and natural gas systems as well as achieving economic and reliable operation of IEGS.

Robust prequalification process of a distribution system operator considering N‐1 contingency

“…However, it did not control wind farms because it treated wind power as a negative demand. Chen et al [27] proposed integrated coordination scheduling of electricity and natural gas systems considering transmission N-1 contingencies, but the uncertainty of DRES was not considered. Vrakopoulou et al [28] proposed a probabilistic framework for reserve scheduling considering N-1 security assessment.…”

“…Chen et al. [27] proposed integrated coordination scheduling of electricity and natural gas systems considering transmission N‐1 contingencies, but the uncertainty of DRES was not considered. Vrakopoulou et al.…”

Contingency analysis for gas transport networks with hydrogen injection

“…A respective analysis is performed for two single elements, namely one compressor and one storage facility, of a small gas network with 25 nodes coupled to a modified IEEE 30-bus system. Chen et al (2019) considers N − 1 contingencies w.r.t. electricity transmission lines only and presents a small benchmark case.…”

Cascading Failure Propagation Simulation in Integrated Electricity and Natural Gas Systems

“…All the other parameters are empirical parameters of compressors, which can be referred to [10]. Equation (1) indicates that the electric power consumption is determined by the pressure ratio between suction and discharging as well as mass flow rate through it. The natural gas mass flow rate running through a compressor with the pressure lifting is constrained by:…”

“…W ITH the increasing installation of energy coupling components such as gas-fired generators and electricity-driven gas compressors, the electricity system has been coupled with the natural gas system more intensively, forming the integrated electricity and natural gas system (IEGS) [1], [2]. Specifically, gas-fired generators serve as power sources in the electricity system and as gas loads in the gas system.…”